UNITED STATES
SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

Commission File Number: 1-7884

MESA ROYALTY TRUST
(Exact name of registrant as specified in its charter)

1-713-483-6020
(Registrant's Telephone Number, Including Area Code)

         Securities registered pursuant to Section 12(b) of the Act:

         Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. Yes ý    No o

         Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit such files). Yes o    No o

         Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company, or an emerging growth company. See the definitions of "large accelerated filer," "accelerated filer," "smaller reporting company," and "emerging growth company" in Rule 12b-2 of the Exchange Act.

         If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. o

         Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). Yes o    No ý

         As of August 14, 2019—May 15, 2020—1,863,590 Units of Beneficial Interest were outstanding in Mesa Royalty Trust.

DISCLOSURES REGARDING FORWARD-LOOKING STATEMENTS

        This Form 10-Q includes "forward-looking statements" about Mesa Royalty Trust (the "Trust") and other matters discussed herein that are subject to risks and uncertainties that are intended to qualify for the safe harbor from liability established by the Private Securities Litigation Reform Act of 1995 and Section 21E of the Securities Exchange Act of 1934, as amended (the "Exchange Act"). All statements other than statements of historical fact included in this document, including, without limitation, statements under "Trustee's Discussion and Analysis of Financial Condition and Results of Operations," including the Trust's or any Working Interest Owner's (as defined in "Note 1—Trust Organization and Provisions") future financial position, status in any insolvency proceeding, business strategy, budgets, projected costs, plans and objectives for future operations, oil and natural gas prices, information regarding target distributions, statements regarding reconciliation and adjustment of estimated versus actual revenue and expense amounts, statements pertaining to future development activities and costs, statements regarding the number of development wells to be completed in future periods, and information regarding production and reserve growth, are forward-looking statements. Actual outcomes and results, which are substantially all outside of the Trust's control, may differ materially from those projected. Forward-looking statements are generally accompanied by words such as "estimate," "project," "predict," "believe," "expect," "anticipate," "potential," "possibly," "could," "may," "can," "foresee," "plan," "goal," "assume," "target," "should," "intend" or other words that convey the uncertainty of future events or outcomes. These statements are based on certain assumptions made by the Trust in light of its experience and perception of historical trends, current conditions and expected future developments, as well as other factors we believe are appropriate under the circumstances. The Trustee (as defined herein) relies on the Working Interest Owners for information regarding the Subject Interests (as defined in "Note 1—Trust Organization and Provisions"), the Royalty (as defined in "Note 1—Trust Organization and Provisions"), and the Working Interest Owners themselves.

        Although the information provided by the Working Interest Owners provides a reasonable basis for the forward-looking statements contained herein, no assurance can be given that such expectations will prove to be correct. Whether actual results and developments will conform with such expectations and predictions is subject to a number of risks and uncertainties, including the risk factors discussed in Part I, Item 1A of the Trust's Annual Report on Form 10-K for the year ended December 31, 2018,2019, Part II, Item 1A of the risk factors discussed herein,Trust's Quarterly Report on Form 10-Q for the quarter ended March 31, 2020 and those set forth from time to time in the Trust's filings with the Securities and Exchange Commission (the "SEC"), which could affect the future results of the energy industry in general, and the Trust and Working Interest Owners in particular, and could cause those results to differ materially from those expressed in such forward-looking statements. The actual results or developments anticipated may not be realized or, even if substantially realized, they may not have the expected consequences to or effects on the Working Interest Owners' businesses and the Trust. Such statements are not guarantees of future performance and actual results or developments may differ materially from those projected in such forward-looking statements. The Trust undertakes no obligation to publicly update or revise any forward-looking statements, except as required by applicable law.

PART I—FINANCIAL INFORMATION

Item 1.    Financial Statements.

MESA ROYALTY TRUST

STATEMENTS OF DISTRIBUTABLE INCOME

(Unaudited)

STATEMENTS OF ASSETS, LIABILITIES AND TRUST CORPUS

(The accompanying notes are an integral part of these financial statements.)

MESA ROYALTY TRUST

STATEMENTS OF CHANGES IN TRUST CORPUS

(Unaudited)

(The accompanying notes are an integral part of these financial statements.)

MESA ROYALTY TRUST

NOTES TO FINANCIAL STATEMENTS

(Unaudited)

Note 1—Trust Organization and Provisions

        The Mesa Royalty Trust (the "Trust"), created under the laws of the State of Texas, maintains its offices at the office of the Trustee, The Bank of New York Mellon Trust Company, N.A., (the "Trustee"), 601 Travis Street, Floor 16, Houston, Texas 77002. The telephone number of the Trust is 713-483-6020. The Bank of New York Mellon Trust Company, N.A., is the successor Trustee from JP MorganJPMorgan Chase Bank, N.A., which is the successor by mergers to the originally named Trustee, Texas Commerce Bank National Association. The Trust has no employees. Administrative functions of the Trust are performed by the Trustee. The Trustee maintains a website for the Trust that makes available, free of charge, filings by the Trust with the Securities and Exchange Commission ("SEC") and other information. Any reports filed with the SEC are accessible through our website as soon as reasonably practicable after we electronically file such material with, or furnish it to, the SEC. The Trust's website is http://mtr.investorhq.businesswire.com/.

        Trust Corpus Description.    The Mesa Royalty Trust (the "Trust") was created on November 1, 1979 and is now governed by the Mesa Royalty Trust Indenture (as amended, the "Trust Indenture"). Through a series of conveyances, assignments, and acquisitions, the Trust currently owns an overriding royalty interest (the "Royalty") equal to 11.44% of 90% of the Net Proceeds (as defined in the Conveyance and described below) attributable to the specified interest in certain producing oil and gas properties located in the:

•

Hugoton field of Kansas (the "Hugoton Royalty Properties");



•

San Juan Basin field of New Mexico (the "San Juan Basin—New Mexico Properties"); and



•

San Juan Basin field of Colorado (the "San Juan Basin—Colorado Properties", and together with the San"San Juan Basin—New Mexico Properties, the "San Juan Basin Royalty Properties", and together with the Hugoton Royalty Properties, the "Royalty Properties").

        Trust Corpus Conveyance History.    On November 1, 1979, Mesa Petroleum Co., predecessor to Mesa Limited Partnership ("MLP"), which was the predecessor to MESA Inc., conveyed to the Trust the Royalty equal to 90% of the Net Proceeds (as defined in the Conveyance and described below) attributable to the specified interests in properties conveyed by the assignor on that date (the "Subject Interests"). The Subject Interests consisted of interests in the Royalty Properties described above. The Royalty is evidenced by counterparts of an Overriding Royalty Conveyance, dated as of November 1, 1979 (the "Conveyance"). In 1985, the Trust Indenture was amended, and the Trust conveyed to an affiliate of Mesa Petroleum Co. 88.5571% of the original Royalty (such transfer, the "1985 Assignment"). The effect of the 1985 Assignment was an overall reduction of approximately 88.56% in the size of the Trust. As a result, the Trust is now entitled to receive 11.44% of 90% of the Net Proceeds attributable to the Royalty Properties each month.

        Hugoton Royalty Properties.    Until August 7, 1997, MESA Inc. operated the Hugoton Royalty Properties through Mesa Operating Co., a wholly owned subsidiary of MESA Inc. On August 7, 1997, MESA Inc. merged with and into Pioneer Natural Resources Company ("Pioneer"), formerly a wholly

MESA ROYALTY TRUST

NOTES TO FINANCIAL STATEMENTS (Continued)

(Unaudited)

Note 1—Trust Organization and Provisions (Continued)

MESA Inc. merged with and into Pioneer Natural Resources Company ("Pioneer"), formerly a wholly owned subsidiary of MESA Inc., and Parker & Parsley Petroleum Company merged with and into Pioneer Natural Resources USA, Inc. (successor to Mesa Operating Co.), a wholly owned subsidiary of Pioneer ("PNR") (collectively, the mergers are referred to herein as the "Merger"). Subsequent to the Merger, the Hugoton Royalty Properties were operated by PNR until December 31, 2014, at which point Linn Energy Holdings, LLC, a subsidiary of Linn Energy, LLC ("Old Linn") took over as operator. Pursuant to the bankruptcy proceedings and court-approved plans of reorganization involving Old Linn, which are described in detail below, Linn Energy, Inc. (together with its subsidiaries, "Linn") became the operator of the Hugoton Royalty Properties on February 28, 2017. On April 18, 2018, Linn announced its Board of Directors' decision to separate Linn into two stand-alone public companies. On August 7, 2018 Linn completed the spin-off of Riviera Resources, Inc. ("Riviera") through the pro rata distribution of all of the shares of Riviera's outstanding common stock to Linn's stockholders. In connection with such distribution, Linn ceased to be the operator of the Hugoton Royalty Properties, and sincestarting on August 7, 2018, Riviera operated the Hugoton Royalty Properties. On November 22, 2019, Riviera completed the sale of its interest in its remaining properties located in the Hugoton Basin under the Purchase and Sale Agreement, dated August 28, 2019 (the "Purchase Agreement"), by and among Riviera Upstream, LLC, Riviera Operating, LLC and Scout Energy Group V, LP ("Scout"). Pursuant to the Purchase Agreement, Riviera divested all of its interest in oil and gas assets and contracts in the Hugoton Royalty Properties. Since November 23, 2019, Scout has operated the Hugoton Royalty Properties.

        San Juan Basin—Colorado Properties.    On April 30, 1991, MLP sold to Conoco, Inc. ("ConocoPhillips") its interests in the San Juan Basin Royalty Properties (the "San Juan Basin Sale"). The Trust's interest in the San Juan Basin Royalty Properties was conveyed from PNR's working interest in 31,328 net producing acres in northwestern New Mexico and southwestern Colorado. ConocoPhillips sold the portion of its interests in the San Juan Basin—Colorado Properties to MarkWest Energy Partners, Ltd. (effective January 1, 1993) and Red Willow Production Company ("Red Willow") (effective April 1, 1992). On October 26, 1994, MarkWest Energy Partners, Ltd. sold substantially all of its interest in the San Juan Basin—Colorado Properties to BP Amoco Company ("BP"), a subsidiary of BP p.l.c. BP and Red Willow currently operate the San Juan Basin—Colorado Properties.

        San Juan Basin—New Mexico Properties.    Starting from the date of the San Juan Basin Sale and ending on July 31, 2017, ConocoPhillips operated substantially all of the San Juan Basin—New Mexico Properties, except a smallan immaterial number of properties that had been assigned to XTO Energy, Inc. ("XTO") effective January 1, 2005. On July 31, 2017, ConocoPhillips sold its San Juan Basin assets to Hilcorp San Juan LP ("Hilcorp"), an affiliate of Hilcorp Energy Company. On March 29, 2018, XTO sold to Hilcorp its interests inan immaterial number of properties, which comprise certain portions of the San Juan Basin—New Mexico Properties. Hilcorp currently operates all of the San Juan Basin—New Mexico Properties.

MESA ROYALTY TRUST

NOTES TO FINANCIAL STATEMENTS (Continued)

(Unaudited)

Note 1—Trust Organization and Provisions (Continued)

        Following Hilcorp's acquisition of ConocoPhillips' and XTO's interests in the San Juan Basin—New Mexico Properties, there was a transition period to transfer historical information, knowledge and processes from one owner to the other. During this transition period, Hilcorp recorded estimates of revenues and expenses and made payments to the Trust based on historical amounts previously paid by ConocoPhillips, and the Trust recognized such amounts in accordance with its modified cash basis of accounting. Accordingly, Hilcorp made an estimated monthly payment of $97,150 in Net Proceeds to

MESA ROYALTY TRUST

NOTES TO FINANCIAL STATEMENTS (Continued)

(Unaudited)

Note 1—Trust Organization and Provisions (Continued)

the Trust from September 2017 to March 2019 based upon the July 2017 production month previously paid by ConocoPhillips. In April 2019, Hilcorp began to generate actual (instead of estimated) Net Proceeds due to the Trust on a monthly basis. Hilcorp has informed the Trust that it will utilize actual revenue and expense amounts and either add or subtract reconciled historical amounts on a month-by-monthmonth by month basis, which will be recognized over time by the Trust in accordance with the Trust's modified cash basis of accounting. In December 2019, Hilcorp made the first payment to the Trust in reconciling historical amounts for one accounting month, which totaled $29,698. For the three months ended March 31, 2020, Hilcorp reconciled three additional historical amounts for the accounting months of October through December 2017, in which the Trust received additional payments of $10,578 for these months. Until all estimated historical monthly amounts received by the Trust from September 2017 to March 2019 are fully reconciled and adjusted, Net Proceeds from the San Juan—New Mexico Properties will reflect adjustments to actual current production and costs to account for historical monthly reconciliations as they are completed. Because of anticipated future adjustments, the amounts of Net Proceeds reported for the San Juan Basin—New Mexico Properties during the three months ended June 30, 2019March 31, 2020 may not be representative of Net Proceeds that will be received in future quarters.

        Hilcorp has informed the Trust that significant incremental costs of approximately $1.1 million attributable to the Trust were incurred in 2018 with respect to a newly drilled well in the San Juan Basin—New Mexico Properties. Incremental costs attributable to the Trust will reduce the Trust's future Net Proceeds over a period of time as adjustments are made by Hilcorp after taking into accountconsidering actual revenues as well as costs for these properties during the applicable time period. The potential impact to Net Proceeds depends upon the results of all of the reconciliation work currently being conducted by Hilcorp and is therefore uncertain. The Trust will undertake a review of the reconciliation calculations by Hilcorp and the amount of Net Proceeds calculated and paid and intends to engage third party consultants when appropriate to assist in the Trust's review.

        Pursuant to the Trust Indenture, the Trust is not required to pay to Hilcorp any amounts that could be owed if the estimated revenue exceeded actual revenue amounts or estimated expenses were less than actual expense amounts in past periods. However, Hilcorp may recover such amounts by withholding a portion or all of the Net Proceeds that would otherwise be payable to the Trust in subsequent periods. This could result in a decrease in Net Proceeds paid to the Trust and could result in future material reductions in distributions to the Trust's unitholders.

MESA ROYALTY TRUST

NOTES TO FINANCIAL STATEMENTS (Continued)

(Unaudited)

Note 1—Trust Organization and Provisions (Continued)

        Net Proceeds from the San Juan Basin—New Mexico Properties for the three months ended June 30,March 31, 2020 and 2019 and 2018 were $312,106$175,986 and $291,449, respectively, which revenue accounted for approximately 53%47% and 55%, respectively, of the total Royalty income reported by the Trust during those periods. Net Proceeds from the San Juan Basin—New Mexico Properties for the six months ended June 30, 2019 and 2018 were $603,555 and $582,898, respectively, which revenue accounted for approximately 46% and 46%40%, respectively, of the total Royalty income reported by the Trust during those periods.

        As used in this report, RivieraScout refers to the current operator of the Hugoton Royalty Properties, Hilcorp refers to the current operator of the San Juan Basin—New Mexico Properties, and BP and Red Willow refer to the current co-operators of certain tracts of land included in the San Juan Basin—Colorado Properties, unless otherwise indicated. Riviera,Scout, BP, Red Willow and Hilcorp are each

MESA ROYALTY TRUST

NOTES TO FINANCIAL STATEMENTS (Continued)

(Unaudited)

Note 1—Trust Organization and Provisions (Continued)

individually referred to herein as "Working Interest Owner" or collectively as the "Working Interest Owners."

        The Royalty Properties are required to be operated by the Working Interest Owners in accordance with reasonable and prudent business judgment and good oil and gas field practices. Each Working Interest Owner has the right to abandon any well or lease if, in its opinion, such well or lease ceases to produce or is not capable of producing oil, gas or other minerals in commercial quantities. Each Working Interest Owner markets the production on terms deemed by it to be the best reasonably obtainable in the circumstances. See "Contracts" under Part I, Item 1 of the Trust's Annual Report on Form 10-K for the year ended December 31, 2018.2019. The Trustee has no power or authority to exercise any control over the operation of the Royalty Properties the incurrence of costs, or the marketing of production therefrom.

        Trustee and Terms of Trust Indenture.    Effective October 2, 2006, the Trustee succeeded JP Morgan Chase Bank, N.A. as Trustee of the Trust. The Trust is a passive entity whose purposes are limited to: (1) converting the Royalty to cash, either by retaining it and collecting the proceeds of production (until production has ceased or the Royalty is otherwise terminated) or by selling or otherwise disposing of the Royalties; and (2) distributing such cash, net of amounts for payments of liabilities to the Trust, to the unitholders. The Trust has no sources of liquidity or capital resources other than the revenues, if any, attributable to the Royalties and interest on cash held by the Trustee as a reserve for liabilities or for distribution. The terms of the Trust Indenture provide, among other things, that:

        (a)   the Trust cannot engage in any business or investment activity or purchase any assets;

        (b)   the Royalty can be sold in part or in total for cash upon approval by the unitholders;

        (c)   the Trustee can establish cash reserves and borrow funds to pay liabilities of the Trust and can pledge assets of the Trust to secure payment of the borrowings;

        (d)   the Trustee will make cash distributions to the unitholders in January, April, July and October each year as discussed more fully in "Note 2—Basis of Presentation";

        (e)   the Trust will terminate upon the first to occur of the following events: (i) at such time as the Trust's royaltyRoyalty income for two successive years is less than $250,000 per year or (ii) a vote by the





MESA ROYALTY TRUST

NOTES TO FINANCIAL STATEMENTS (Continued)

(Unaudited)

Note 1—Trust Organization and Provisions (Continued)

unitholders in favor of termination. Upon termination of the Trust, the Trustee will sell for cash all the assets held in the Trust estate and make a final distribution to unitholders of any funds remaining after all Trust liabilities have been satisfied; and

        (f)    Riviera,Scout, Hilcorp and BP will reimburse the Trust for 59.34%, 27.45% and 1.77%, respectively, offor general and administrative expenses of the Trust.

        Trustee's Fees.    Pursuant to the Trust Indenture, the Trust pays the Trustee fees for its services each quarter and the Working Interest Owners partially reimburse the Trust for the fees paid in

MESA ROYALTY TRUST

NOTES TO FINANCIAL STATEMENTS (Continued)

(Unaudited)

Note 1—Trust Organization and Provisions (Continued)

connection with the Trustee's services. The net amount of these reimbursements is included in the general and administrative expenses of the Trust. For the quarter ended June 30, 2019,March 31, 2020, the Trustee was due $118,750 for its services. The Trust paid $108,288 of this amount to the Trustee, and $10,462 was allocated to offset against interest due to the Trust under the Trust Indenture. The Trustee was due $237,500 for its services for the six months ended June 30, 2019. The Trust paid $216,576 of this amount to the Trustee and $20,924 was allocated to offset against interest due to the Trust under the Trust Indenture. The Trust Indenture requires that cash being held by the Trustee earn interest at 1.5% below the prime rate, which would have yielded the Trust a 4.00%3.25% annualized return from January 1, 20192020 through June 30, 2019.March 2, 2020, a 2.75% annualized return from March 3, 2020 through March 14, 2020 and a 1.75% annualized return from March 15, 2020 through March 31, 2020. However, due to the current interest rate environment, the Trustee was unable to obtain an account in which such an interest rate was available. In the event such an interest rate is unavailable in the future, the Trustee intends to allocate certain of its fees due to the Trust to meet the minimum interest rate payable under the Trust Indenture. In future periods the Trustee will continue to allocate a portion of the fees earned for its services to the Trust until all remaining interest due to the Trust is fully offset.

        The Working Interest Owners partially reimburse the Trust each quarter for amounts paid in connection with the Trustee's services. For the quarter ended June 30, 2019,March 31, 2020, the Trustee's fees were $108,288 and the Working Interest Owners reimbursed a sum of $95,897 to the Trustee, which was the same amount reimbursed for the quarter ended June 30, 2018. For the six months ended June 30, 2019, the Trustee's fees were $216,576 and the Working Interest Owners reimbursed a sum of $191,794 to the Trustee, which was the same amount reimbursed for the six months ended June 30, 2018.

        Linn Energy, LLC Reorganization.    On May 11, 2016, Old Linn, LinnCo, LLC ("LinnCo"), an affiliate of Old Linn, and certain of Old Linn's direct and indirect subsidiaries (collectively with Old Linn and LinnCo, the "Debtors"), filed voluntary petitions for reorganization under Chapter 11 of the United States Bankruptcy Code in the United States Bankruptcy Court for the Southern District of Texas (the "Court"). The Debtors' Chapter 11 cases were administered jointly under the captionIn re Linn Energy, LLC, et al., Case No. 16-60040.

        On January 27, 2017, the Court entered theOrder Confirming (I) Amended Joint Chapter 11 Plan of Reorganization of Linn Energy, LLC and its Debtor Affiliates Other Than Linn Acquisition Company, LLC and Berry Petroleum Company, LLC and (II) Amended Joint Chapter 11 Plan of Reorganization of Linn Acquisition Company, LLC and Berry Petroleum Company, LLC, which approved and confirmed the Amended Joint Chapter 11 Plan of Reorganization of Linn Energy, LLC and Its Debtor Affiliates Other Than Linn Acquisition Company, LLC and Berry Petroleum Company, LLC (the "Plan"). The Plan became effective on February 28, 2017 (the "Effective Date").

        Pursuant to the Plan, on the Effective Date, all assets of Old Linn (other than equity interests in Linn Acquisition Company, LLC and Berry Petroleum Company, LLC) were conveyed to Linn Energy, Inc. (or a subsidiary thereof), and LinnCo, LLC and Linn Energy, LLC were wound down and liquidated. Subsequent to the effectiveness of the Plan, Linn Energy, Inc. became the reorganized

MESA ROYALTY TRUST

NOTES TO FINANCIAL STATEMENTS (Continued)

(Unaudited)

Note 1—Trust Organization and Provisions (Continued)

successor to Old Linn. Under the Plan Supplement, as amended, filed with the Court, the Debtors assumed all executory contracts and unexpired leases with the Trust and Mesa Operating Limited Partnership as the counterparty. Furthermore, pursuant to the Plan, the royalty interests in the Hugoton Royalty Properties owned by the Trust shall be preserved and remain in full force and effect in accordance with the terms of the granting instruments or other governing documents. On April 18, 2018, Linn announced its Board of Directors' decision to separate Linn into two stand-alone public companies. On August 7, 2018, Linn completed the spin-off of Riviera through the pro rata distribution of all of the shares of Riviera's outstanding common stock to Linn's stockholders. In connection with such distribution, Linn ceased to be the operator of the Hugoton Royalty Properties, and since August 7, 2018, Riviera has operated the Hugoton Royalty Properties.March 31, 2019.

        Discussion of Net Proceeds.    The Conveyance provides for a monthly computation of Net Proceeds. Net Proceeds is defined in the Conveyance as the "Gross Proceeds" received by the Working Interest Owners during a particular period, minus certain production and capital costs for such period. "Gross Proceeds" is defined in the Conveyance as the amount received by the Working Interest Owners from the sale of "Subject Minerals", subject to certain adjustments. "Subject Minerals" means all oil, gas and other minerals, whether similar or dissimilar, in and under, and which may be produced, saved and sold from, and which accrue and are attributable to, the Subject Interests from and after November 1, 1979. "Production costs" means, generally, costs incurred on an accrual basis by the Working Interest Owners in operating the Royalty Properties, including capital and non-capital costs. If production and capital costs exceed Gross Proceeds for any month, the excess, plus interest thereon at 120% of the prime rate of Bank of America, is recovered out of future Gross Proceeds prior to the making of further payment to the Trust. The Trust, however, is generally not liable for any operating costs or other costs or

MESA ROYALTY TRUST

NOTES TO FINANCIAL STATEMENTS (Continued)

(Unaudited)

Note 1—Trust Organization and Provisions (Continued)

liabilities attributable to the Royalty Properties or minerals produced therefrom. The Trust is not obligated to return any Royalty income received in any period.

        The Working Interest Owners are required to maintain books and records sufficient to determine the amounts payable under the Royalty. Additionally, in the event of a controversy between a Working Interest Owner and any purchaser as to the correct sales price for any production, amounts received by such Working Interest Owner and promptly deposited by it with an escrow agent are not considered to have been received by such Working Interest Owner, and, therefore, are not subject to being payable with respect to the Royalty until the controversy is resolved; but all amounts thereafter paid to such Working Interest Owner by the escrow agent will be considered amounts received from the sale of production. Similarly, operating costs include any amounts a Working Interest Owner is required to pay whether as a refund, interest or penalty to any purchaser because the amount initially received by such Working Interest Owner as the sales price was in excess of that permitted by the terms of any applicable contract, statute, regulation, order, decree or other obligation. Within 30 days following the close of each calendar quarter, the Working Interest Owners are required to deliver to the Trustee a statement of the computation of Net Proceeds attributable to such quarter.

MESA ROYALTY TRUST

NOTES TO FINANCIAL STATEMENTS (Continued)

(Unaudited)

Note 1—Trust Organization and Provisions (Continued)

        The brief discussions of the Trust Indenture and the Conveyance contained herein are qualified in their entirety by reference to the Trust Indenture and the Conveyance themselves, which are exhibits to the Trust's Annual Report on Form 10-K for the year ended December 31, 20182019 and are available upon request from the Trustee.

Note 2—Basis of Presentation

        The accompanying unaudited financial information has been prepared by the Trustee in accordance with the instructions to Form 10-Q. The preparation of the financial statements requires estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent liabilities at the date of the financial statements and the reported amounts of income and expenses during the reporting period. Actual results could differ from those estimates. The Trustee believes such information includes all the disclosures necessary to make the information presented not misleading. The information furnished reflects all adjustments which are, in the opinion of the Trustee, necessary for a fair presentation of the results for the interim periods presented. The financial information should be read in conjunction with the financial statements and notes thereto included in the Trust's Annual Report on Form 10-K for the year ended December 31, 2018.2019. The Trust considers all highly liquid investments with a maturity of three months or less to be cash equivalents. Subsequent events were evaluated through the issuance date of the financial statements.

        In accordance with the Conveyance, the Working Interest Owners are obligated to calculate and pay the Trust each month an amount equal to 11.44% of 90% of the Net Proceeds (as defined in the Conveyance) attributable to the month.

MESA ROYALTY TRUST

NOTES TO FINANCIAL STATEMENTS (Continued)

(Unaudited)

Note 2—Basis of Presentation (Continued)

        The financial statements of the Trust are prepared on the following basis:

        (a)   Royalty income recorded for a month is the amount computed and paid by the Working Interest Owners to the Trustee for such month rather than either the value of a portion of the oil and gas produced by the Working Interest Owners for such month or the amount subsequently determined to be the Trust's proportionate share of the net proceedsNet Proceeds for such month;

        (b)   Interest income, interest receivable and distributions payable to unitholders include interest to be earned on short-term investments from the financial statement date through the next date of distribution;

        (c)   Trust general and administrative expenses, net of reimbursements, are recorded in the month they are included in the calculation of the monthly distribution amount;

        (d)   Amortization of the Royalty is computed on a unit-of-production basis and is charged directly to trust corpus because such amount does not affect distributable income; and

        (e)   Distributions payable are determined on a monthly basis and are payable to unitholders of record as of the last business day of each month or such later date as the Trustee determines is

MESA ROYALTY TRUST

NOTES TO FINANCIAL STATEMENTS (Continued)

(Unaudited)

Note 2—Basis of Presentation (Continued)

required to comply with applicable law or stock exchange requirements. However, cash distributions are made quarterly in January, April, July and October, and include interest earned from the monthly record dates to the date of distribution.

        This basis for reporting distributable income is considered to be the most meaningful because distributions to the unitholders for a month are based on net cash receipts for such month. However, these statements differ from financial statements prepared in accordance with accounting principles generally accepted in the United States of America because, under such principles, royaltyRoyalty income for a month would be based on net proceedsNet Proceeds from production for such month without regard to when calculated or received, general and administrative expenses would be recorded in the month they accrue, and interest income for a month would be calculated only through the end of such month.

Note 3—Legal Proceedings

        There are no pending legal proceedings to which the Trust is a named party. The Trustee has been advised by the Working Interest Owners that the Trust may be subject to litigation in the ordinary course of business for certain matters that include the Royalty Properties. While each of the Working Interest Owners has advised the Trustee that it does not currently believe any of the pending litigation will have a material adverse effect net to the Trust, in the event such matters were adjudicated or settled in a material amount and charges were made against Royalty income, such charges could have a material impact on future Royalty income.

MESA ROYALTY TRUST

NOTES TO FINANCIAL STATEMENTS (Continued)

(Unaudited)

Note 4—Income Tax Matters

        In a technical advice memorandum dated February 26, 1982, the Internal Revenue Service (the "IRS") advised the Dallas District Director that the Trust is classifiable as a grantor trust and not as an association taxable as a corporation. As a grantor trust, the Trust incurs no federal income tax liability and each unitholder is subject to tax on the unitholder's pro rata share of the income and expense of the Trust as if the unitholder were the direct owner of a pro rata share of the Trust's assets. In addition, there is no state tax liability for the period.

        U.S. federal tax reform informally known as the Tax Cuts and Jobs Act (the "TCJA") was enacted on December 22, 2017 and made significant changes to the federal income tax rules applicable to both individuals and entities, including changes to the effective tax rate on a unitholder's allocable share of certain income from the Trust. The TCJA is complex and some areas lack administrative guidance. Thus, unitholders should consult their tax advisor regarding the TCJA and its effect on an investment in Trust units.

Individuals, estates, and trusts with income above certain thresholds are subject under Section 1411 of the Code to an additional 3.8% tax—also known as the Net Investment Income Tax ("NIIT")—on their net investment income. Grantor trusts such as theMesa Royalty Trust are not subject to the NIIT; however, the

MESA ROYALTY TRUST

NOTES TO FINANCIAL STATEMENTS (Continued)

(Unaudited)

Note 4—Income Tax Matters (Continued)

unitholders may be subject to the tax. For these purposes, investment income would generally include certain income derived from investments, such as the royalty income derived from the units and gain realized by a unitholder from a sale of units.

        The Trustee assumes that some Trust units are held by a middleman, as such term is broadly defined in U.S. Treasury Regulations (and includes custodians, nominees, certain joint owners, and brokers holding an interest for a custodian in street name). Therefore, the Trustee considers the Trust to be a non-mortgage widely held fixed investment trust ("WHFIT") for U.S. federal income tax purposes. The Bank of New York Mellon Trust Company, N.A., 601 Travis Street, Floor 16, Houston, Texas 77002, telephone number 713-483-6020, is the representative of the Trust that will provide tax information in accordance with applicable U.S. Treasury Regulations governing the information reporting requirements of the Trust as a WHFIT.

        Notwithstanding the foregoing, the middlemen holding units on behalf of unitholders, and not the Trustee of the Trust, are solely responsible for complying with the information reporting requirements under the Treasury Regulations with respect to such units, including the issuance of IRS Forms 1099 and certain written tax statements. Unitholders whose units are held by middlemen should consult with such middlemen regarding the information that will be reported to them by the middlemen with respect to the units.

        In addition, on March 27, 2020, Congress enacted the Coronavirus Aid, Relief, and Economic Security Act ("CARES Act"), a substantial tax and spending package intended to provide certain relief as a result of the COVID-19 pandemic. The Trustee is currently evaluating the impact to the Trust of the provisions of the CARES Act.

        Each unitholder should consult its own tax advisor with respect to its particular circumstances.

MESA ROYALTY TRUST

NOTES TO FINANCIAL STATEMENTS (Continued)

(Unaudited)

Note 5—Excess Production Costs

        Excess production costs result when costs, charges, and expenses attributable to a working interest propertyRoyalty Property exceed the revenue received from the sale of oil, gas, and other hydrocarbons produced from such property. The excess production costs must be recovered by the Working Interest Owners before any distribution of Royalty income from the properties will be made to the Trust.

Note 6—Distributable Income Per Unit

        The Trust's Royalty income from the Royalty Properties and its distributions to unitholders are heavily influenced by commodity prices. Commodity prices may fluctuate widely in response to (i) relatively minor changes in the supply of and demand for oil and natural gas, (ii) market uncertainty and (iii) a variety of additional factors that are beyond the Trustee's control. Recently, there has been a substantial decrease in oil and natural gas prices due in part to significantly decreased demand as a result of the novel coronavirus ("COVID-19") pandemic and an oversupply of crude oil driven by a dispute between members of the Organization of Petroleum Exporting Countries and Russia over production cuts. Although the above factors have primarily negatively affected oil prices to date, the Trust cannot guarantee that the above factors will not negatively impact natural gas commodity prices. The recent spread of the COVID-19 pandemic, and the measures taken to mitigate the impact of the COVID-19 pandemic, are adversely affecting the business and operations of the Working Interest Owners, which in turn could have an adverse effect on Trust distributions.

During 2011, the Trustee, acting pursuant to the Trust Indenture, withheld $1.0 million for future unknown contingent liabilities and expenses (such cumulative withholding being the "Contingent Reserve"). The Trustee reserves the right to determine whether or not to release cash reserves in future periods with respect to any reimbursement expenses. At any given time, the Contingent Reserve is included in cash and short-term investments.

        For the three months ended March 31, 2020, the Trustee increased the Contingent Reserve by (1) $22,268 of Royalty income received from BP in March 2020 after the distribution to unitholders had been announced for the month of March 2020, which Royalty income was included in the April 2020 distribution to unitholders and (2) $23,629 reimbursement not received from Scout until January 2020 but included in the December 2019 distribution to unitholders. For the three months ended March 31, 2020, the Trustee decreased the Contingent Reserve by (1) $844 due to an overpayment received in error from BP in December 2019 that was deducted from BP's January 2020 payment to

MESA ROYALTY TRUST

NOTES TO FINANCIAL STATEMENTS (Continued)

(Unaudited)

Note 6—Distributable Income Per Unit (Continued)

with respect to any reimbursement expenses. At any given time, the Contingent Reserve isTrust and (2) $147,893 Royalty income for February and March 2020 included in cash and short-term investments.

        For the three months ended June 30, 2019, the Trustee increased the Contingent Reserve by $434 for a duplicated general and administrative expense paid in error by the Trust in February 2019 and not refunded to the Trust until April 2019. For the three months ended June 30, 2019, the Trustee decreased the Contingent Reserve by (1) $56,793 of Royalty income received from BP in March 2019 after the distribution to unitholders had been announced for the month of March 2019, which Royalty income was included in the April 2019 distribution to unitholders and (2) $317 underpaid by Riviera in June 2019 due to a 2018 Ad Valorem tax under accrual but included in the June 2019 distribution to unitholders.

        For the six months ended June 30, 2019, the Trustee increased the Contingent Reserve by (1) $56,793 of Royalty incomenot received from BP in March 2019 after the distribution to unitholders had been announced for the month of March 2019, which Royalty income was included in the April 2019 distribution to unitholders, and (2) $434 for a duplicated general and administrative expense paid in error by the Trust in February 2019 and not refunded to the TrustScout until April 2019.2020.

        For the six months ended June 30, 2019, the Trustee decreased the Contingent Reserve by (1) $434 for a duplicated general and administrative expense paid in error by the Trust in February 2019 and not refunded to the Trust until April 2019, (2) $38,364 for a cash refund of a duplicate payment from a vendor received in November 2018 and distributed to unitholders in February 2019, (3) $56,793 of Royalty income received from BP in March 2019 after the distribution to unitholders had been announced for the month of March 2019, which Royalty income was included in the April 2019 distribution to unitholders, and (4) $317 underpaid by Riviera in June 2019 due to a 2018 Ad Valorem tax under accrual but included in the June 2019 distribution to unitholders.

MESA ROYALTY TRUST

NOTES TO FINANCIAL STATEMENTS (Continued)

(Unaudited)

Note 6—Distributable Income Per Unit (Continued)

        As of June 30, 2019,March 31, 2020, the value of the Contingent Reserve was $999,683,$874,370, which is included in cash and short-term investments. The effect on distributable income per unit of adjustments to the Contingent Reserve is as follows:

Item 2.    Trustee's Discussion and Analysis of Financial Condition and Results of Operations.

        The following review of Mesa Royalty Trust's (the "Trust")the financial condition and results of operations of Mesa Royalty Trust (the "Trust") should be read in conjunction with the financial statements and notes thereto. The discussion of net production attributable to the Hugoton Royalty Properties and San Juan Basin Royalty Properties (as each is defined below) represents production volumes that are to a large extent hypothetical as the Trust does not own and is not entitled to any specific production volumes. Any discussion of "actual" production volumes represents the hydrocarbons that were produced from the properties in which the Trust has an overriding royalty interest, as reported by a Working Interest Ownerinterest. See Note 7 to the financial statements in the Trust's Annual Report on Form 10-K for the applicable period.year ended December 31, 2019.

        The Trust was created on November 1, 1979 and is now governed by the Mesa Royalty Trust Indenture (as amended, the "Trust Indenture"). Through a series of conveyances, assignments, and acquisitions, the Trust currently owns an overriding royalty interest (the "Royalty") equal to 11.44% of 90% of the Net Proceeds (as defined and described in an Overriding Royalty Conveyance dated as of November 1, 1979 (the "Conveyance")) attributable to the specified interest in certain producing oil and gas properties located in the:

•

Hugoton field of Kansas (the "Hugoton Royalty Properties");



•

San Juan Basin field of New Mexico (the "San Juan Basin—New Mexico Properties"); and



•

San Juan Basin field of Colorado (the "San Juan Basin—Colorado Properties", and together with the San"San Juan Basin—New Mexico Properties, the "San Juan Basin Royalty Properties", and together with the Hugoton Royalty Properties, the "Royalty Properties").

        On April 18, 2018, Linn Energy, Inc. (together with its subsidiaries, "Linn") announced its Board of Directors' decision to separate Linn into two stand-alone public companies. On August 7, 2018, LinnNovember 22, 2019, Riviera completed the spin-offsale of its interest in its remaining properties located in the Hugoton Basin under the Purchase and Sale Agreement, dated August 28, 2019 (the "Purchase Agreement"), by and among Riviera Resources, Inc.Upstream, LLC, Riviera Operating, LLC and Scout Energy Group V, LP ("Riviera"Scout") through. Pursuant to the pro rata distribution ofPurchase Agreement, Riviera divested all of the shares of Riviera's outstanding common stock to Linn's stockholders. In connection with such distribution, Linn ceased to be the operator ofits interest in oil and gas assets and contracts in the Hugoton Royalty Properties, and since August 7, 2018, RivieraProperties. Since November 23, 2019, Scout has operated the Hugoton Royalty Properties.

        Pursuant to past conveyances, Scout, Hilcorp, San Juan LP ("Hilcorp"), BP Amoco Company ("BP"), and Red Willow Production Company ("Red Willow") are the operators of certain portions of the Hugoton Royalty Properties and San Juan Basin Royalty Properties (each of Riviera,Scout, Hilcorp, BP and Red Willow being a "Working Interest Owner", and together, the "Working Interest Owners"). As used in this report, RivieraScout refers to the current operator of the Hugoton Royalty Properties, Hilcorp refers to the current operator of the San Juan Basin—New Mexico Properties, and BP and Red Willow refer to the currentcurrents co-operators of certain tracts of land included in the San Juan Basin—Colorado Properties, unless otherwise indicated.

        Any discussion of "actual" production volumes represents the hydrocarbons that were produced from the properties in which the Trust has an overriding royalty interest, as reported by a Working Interest Owner for the applicable period. See Note 7 to the financial statements in the Trust's Annual Report on Form 10-K for the year ended December 31, 2018.

        The Trust is a passive entity whose purposes are limited to: (1) converting the Royalties to cash, either by retaining them and collecting the proceeds of production (until production has ceased or the Royalties are otherwise terminated) or by selling or otherwise disposing of the Royalties; and

(2) distributing such cash, net of amounts for payments of liabilities to the Trust, to the unitholders. The Trust has no sources of liquidity or capital resources other than the revenues, if any, attributable to the Royalties and interest on cash held by The Bank of New York Mellon Trust Company, N.A. ("the Trustee"(the "Trustee") as a reserve for liabilities or for distribution. The Trust does not undertake or control any capital projects or make capital expenditures. While the Trust's Royalty income is net of capital expenditures, these capital expenditures are controlled and paid by the Working Interests Owners, and

the Trust receives Royalty income net of these expenses. In addition, the Trust does not have any off-balance sheet arrangements or other contingent obligations.

Note Regarding Forward-Looking Statements

        This Form 10-Q includes "forward-looking statements" about the Trust and other matters discussed herein that are subject to risks and uncertainties that are intended to qualify for the safe harbor from liability established by the Private Securities Litigation Reform Act of 1995 and Section 21E of the Securities Exchange Act of 1934, as amended. All statements other than statements of historical fact included in this document, including, without limitation, statements under "Trustee's Discussion and Analysis of Financial Condition and Results of Operations," including the Trust's or any Working Interest Owner's future financial position, status in any insolvency proceeding, business strategy, budgets, projected costs, and plans and objectives for future operations, oil and natural gas prices, information regarding target distributions, statements regarding reconciliation and adjustment of estimated versus actual revenue and expense amounts, statements pertaining to future development activities and costs, statements regarding the number of development wells to be completed in future periods, and information regarding production and reserve growth, are forward-looking statements. Actual outcomes and results, which are substantially all outside of the Trust's control, may differ materially from those projected. Forward-looking statements are generally accompanied by words such as "estimate," "project," "predict," "believe," "expect," "anticipate," "potential," "possibly," "could," "may," "can," "foresee," "plan," "goal," "assume," "target," "should," "intend" or other words that convey the uncertainty of future events or outcomes. These statements are based on certain assumptions made by the Trust in light of its experience and perception of historical trends, current conditions and expected future developments, as well as other factors we believe are appropriate under the circumstances. The Trustee relies on the Working Interest Owners for information regarding the Subject Interests (as defined herein in "Note 1—Trust Organization and Provisions"), the Royalty, and the Working Interest Owners themselves.

        Although the information provided by the Working Interest Owners provides a reasonable basis for the forward-looking statements contained herein, no assurance can be given that such expectations will prove to be correct. Whether actual results and developments will conform with such expectations and predictions is subject to a number of risks and uncertainties, including the risk factors discussed in Part I, Item 1A of the Trust's Annual Report on Form 10-K for the year ended December 31, 2018, the risk factors discussed herein,2019 and those set forth from time to time in the Trust's filings with the Securities and Exchange Commission (the "SEC"), which could affect the future results of the energy industry in general, and the Trust and Working Interest Owners in particular, and could cause those results to differ materially from those expressed in such forward-looking statements. The actual results or developments anticipated may not be realized or, even if substantially realized, they may not have the expected consequences to or effects on the Working Interest Owners' businesses and the Trust. Such statements are not guarantees of future performance and actual results or developments may differ materially from those projected in such forward-looking statements. The Trust undertakes no obligation to publicly update or revise any forward-looking statements, except as required by applicable law.

SUMMARY OF ROYALTY INCOME, PRODUCTION AND AVERAGE PRICES

(Unaudited)

        Royalty income is computed after deducting the Trust's proportionate share of capital costs, operating costs and interest on any cost carryforward from the Trust's proportionate share of "Gross Proceeds," as defined in the Conveyance.

        The Trust's Royalty income from the Royalty Properties and its distributions to unitholders are heavily influenced by commodity prices. Commodity prices may fluctuate widely in response to (i) relatively minor changes in the supply of and demand for oil and natural gas, (ii) market uncertainty and (iii) a variety of additional factors that are beyond the Trustee's control. Recently, there has been a substantial decrease in oil and natural gas prices due in part to significantly decreased demand as a result of the novel coronavirus ("COVID-19") pandemic and an oversupply of crude oil driven by a dispute between members of the Organization of Petroleum Exporting Countries and Russia over production cuts. Although the above factors have primarily negatively affected oil prices to date, the Trust cannot guarantee that the above factors will not negatively impact natural gas commodity prices. The recent spread of the COVID-19 pandemic, and the measures taken to mitigate the impact of the COVID-19 pandemic, are adversely affecting the business and operations of the Working Interest Owners, which in turn could have an adverse effect on Trust distributions.

        The following summary illustrates the net effect of the components of the actual Royalty computation for the periods indicated.

Three Months Ended June 30,March 31, 2020 and 2019 and 2018

Financial Review

        Royalty and Interest Income.    The Trust's Royalty income was $588,481$378,284 for the quarter ended June 30, 2019, an increaseMarch 31, 2020, a decrease of approximately 11%48% as compared to $530,259$726,869 for the quarter ended June 30, 2018.March 31, 2019. The increasedecrease was primarily a result of higherreporting only January 2020 Royalty income from Scout because February and March 2020 Royalty income from Scout was not received by the Trust until April 2020. If Royalty income from Scout for February and March 2020 had been received by the Trust in the quarter ended March 31, 2020, the Trust's Royalty income for the quarter would have been $526,177, a decrease of approximately 28% as compared to $726,869 for the quarter ended March 31,2019. This decrease was primarily a result of lower natural gas natural gas liquids and oil and condensate prices, increaseddecreased net production of natural gas liquids and oil and condensate, and a decrease in operating expenses for natural gas and natural gas liquids,higher capital costs, offset in part by higher capital expendituresoil condensate prices and an increase in net production of oil and condensate in the quarter ended June 30, 2019,March 31, 2020, as compared to the quarter ended June 30, 2018.March 31, 2019.

        The Trust's interestInterest income for the quarters ended June 30,March 31, 2020 and 2019 was $4,328 and 2018 was $9,012 and $5,843,$7,972, respectively. In accordance with the Trust Indenture and as explained below, interest on cash on hand was paid at a rate equivalent to a 4.00%3.25% annualized return from January 1, 20192020 through June 30, 2019.March 2, 2020, a 2.75% annualized return from March 3, 2020 through March 14, 2020, and a 1.75% annualized return from March 15, 2020 to March 31, 2020.

        General and Administrative Expense.    General and administrative expense was $50,166$17,639 and $52,096$47,546 for the three months ended June 30,March 31, 2020 and 2019, and 2018, respectively. The Trustee's fees are included in general and administrative expense. The decrease for the three months ended March 31, 2020 as compared to March 31, 2019 was primarily a result of expenses to be reimbursed by Scout in December 2019 in the amount of $23,629 not actually received from Scout until January 2020. If the Trust had received such reimbursement in December 2019, general and administrative expenses for the three months ended March 31, 2020 would have been $41,268.

        For the quarter ended June 30, 2019,March 31, 2020, the Trustee was due $118,750 for its services. The Trust paid $108,288 of this amount to the Trustee, and $10,462 was allocated to offset against interest due to the Trust under the Trust Indenture. The Trust Indenture requires that cash being held by the Trustee earn interest at 1.5% below the prime rate, which would have yielded the Trust a 4.00%3.25% annualized return from January 1, 20192020 through June 30, 2019. March 2, 2020, a 2.75% annualized return from March 3, 2020 through March 14, 2020 and a 1.75% annualized return from March 15, 2020 through March 31, 2020.

However, due to the current interest rate environment, the Trustee was unable to obtain an account in which such an interest rate was available. In the event such an interest rate is unavailable in the future, the Trustee intends to allocate certain of its fees due to the Trust to meet the minimum interest rate payable under the Trust Indenture. In future periods the Trustee will continue to allocate a portion of the fees earned for its services to the Trust until all remaining interest due to the Trust is fully offset.

        Unreimbursed Expenses and the Contingent Reserve.    The Working Interest Owners partially reimburse the Trust each quarter for amounts paid in connection with the Trustee's services. For the quarter ended June 30, 2019,March 31, 2020, the Trustee's fees were $108,288 and the Working Interest Owners reimbursed a sum of $95,897 to the Trustee, which was the same amount reimbursed for the quarter ended June 30, 2018.March 31, 2019. As of each of the quarters ended June 30,March 31, 2020 and 2019, and 2018, there were $0 and $14,501, respectively, of unreimbursed expenses.

        During 2011, the Trustee, acting pursuant to the Trust Indenture, withheld $1.0 million for future unknown contingent liabilities and expenses (such cumulative withholding, the "Contingent Reserve"). The Trustee reserves the right to determine whether or not to release cash reserves in future periods with respect to any reimbursement expenses. For the three months ended June 30, 2019,March 31, 2020, the Trustee increased the Contingent Reserve by $434 for a duplicated general and administrative expense paid in error by the Trust in February 2019 and not refunded to the Trust until April 2019. For the three months ended June 30, 2019, the Trustee decreased the Contingent Reserve by (1) $56,793$22,268 of Royalty income received from BP in March 20192020 after the distribution to unitholders had been announced for the month of March 2019,2020, which Royalty income was included in the April 20192020 distribution to unitholders and (2) $317 underpaid by Riviera in June 2019 due to a 2018 Ad Valorem tax under accrual$23,629 reimbursement not received from Scout until January 2020 but included in the JuneDecember 2019 distribution to unitholders. As of June 30, 2019,For the three months ended March 31, 2020, the Trustee decreased the Contingent Reserve by (1) $844 due to an overpayment received in error from BP in December 2019 that was $999,683, which isdeducted from BP's January 2020 payment to the Trust and (2) $147,893 Royalty Income for February and March 2020 included in cash and short-term investments.the March distribution but not received from Scout until April 2020.

        Distributable Income Available for Distribution.    The portion of the Trust's distributable income available for distribution each period includes the Royalty income received from the Working Interest Owners during such period, plus interest income earned to the date of distribution (if any) and increases or withdrawals from the Contingent Reserve (if any). Distributable income available for distribution for the quarter ended June 30, 2019March 31, 2020 was $604,003,$467,813, representing $0.3241$0.2510 per unit, compared to $550,605,$669,300, representing $0.2955$0.3591 per unit, for the quarter ended June 30, 2018.March 31, 2019. Based on 1,863,590 units outstanding for the quarters ended June 30,March 31, 2020 and 2019, and 2018, respectively, the per unit distributions for each month in such periods were as follows:

Operational Review

        The business of the Working Interest Owners is being adversely affected by the COVID-19 pandemic and measures being taken to mitigate its impact. The oil and gas industry is experiencing a sharp and rapid decline in the demand for crude oil and natural gas worldwide. The global economy and commodity prices are being severely negatively impacted, as economic activity is curtailed in response to the COVID-19 pandemic, as well as due to other geopolitical factors. Official restrictions on non-essential activities, including "shelter in place" and "stay at home" orders, have been introduced throughout the U.S. and the world, and in some places are being extended into the summer of 2020, which may impact the Working Interest Owners' production activities. The length of time that such measures are in place is likely to further adversely affect Trust distributions. Fewer businesses than normal are open and fewer people are traveling to work, which has greatly reduced the demand for oil and natural gas worldwide. Additionally, the Working Interest Owners' reliance on third-party suppliers, contractors, and service providers exposes them to possibility of delay or interruption of operations. At this time, the full extent to which the COVID-19 pandemic will negatively impact the global economy and the oil and gas industry is uncertain, but pandemics or other significant public health events could have a material adverse effect on the Working Interest Owners' business and financial condition, which could have an adverse effect on Trust distributions.

Hugoton Royalty Properties

        Natural gas and natural gas liquids production attributable to the Hugoton Royalty Properties accounted for approximately 28%27% of the Royalty income of the Trust during the secondfirst quarter of 2019.2020.

        Royalty Income.    Royalty income attributable to the Hugoton Royalty Properties increaseddecreased to $162,600$100,552 in the secondfirst quarter of 20192020 from $142,228$183,926 in the secondfirst quarter of 20182019. The decrease was primarily duea result of reporting only January 2020 Royalty income from Scout because February and March 2020 Royalty income from Scout was not received by the Trust until April 2020. If Royalty income from Scout for February and March 2020 had been received by the Trust in the quarter ended March 31, 2020, the Trust's Royalty income for the quarter would have been $248,445, an increase of approximately 35% as compared to increases in natural gas prices,$183,926 for the quarter ended March 31, 2019. This increase was primarily a result of increased net production of natural gas and natural gas liquids production volumes and lower operating costs, offset in part by lower natural gas and natural gas liquids prices from the Hugoton Royalty Properties in the secondfirst quarter of 20192020 compared to the secondfirst quarter of 2018.2019.

        Operating Costs and Capital Expenditures.    Operating costs were $273,286$13,726 in the secondfirst quarter of 2019,2020, as compared to $345,590 in the first quarter of 2019. The decrease was primarily a result of reporting only January 2020 operating costs from Scout because February and March operating costs are not recognized until the receipt of Royalty income which income for February and March was not received by the Trust until April 2020. If operating costs were reported for all three months in the

quarter ended March 31, 2020, the operating costs would have been $235,749 in the first quarter of 2020, a decrease of approximately 27%32% as compared to $376,717$345,590 in the secondfirst quarter of 2018, primarily2019. However, because final settlement of the acquisition by Scout from the prior Working Interest Owner, Riviera, has not occurred as of March 31, 2020, Scout has informed the Trustee that the variance is due to lower ad valorem taxes during the second quarteroutstanding expenses not yet settled with Riviera and expenses from vendors not yet received as a result of 2019.transition of operations to Scout. Capital expenditures attributable to the Hugoton Royalty Properties were $1$0 in the secondfirst quarter of 2019, as compared to $7 in the second quarter of 2018.both 2020 and 2019.

        Average Sales Price.    Average sales prices per thousand cubic feet ("Mcf") of natural gas and barrel ("Bbl") for natural gas liquids for the Hugoton Royalty Properties are directly dependent on the prices RivieraScout realizes for natural gas sold under short-term and multi-month contracts at market clearing prices to multiple purchasers. Overall market prices received for natural gas from Hugoton Royalty Properties were higherlower for the three months ended June 30, 2019March 31, 2020 as compared to the three months ended June 30, 2018.March 31, 2019.

        Linn Energy Reorganization.    On May 11, 2016, Linn Energy, LLC ("Old Linn"), LinnCo, LLC ("LinnCo"), an affiliate of Old Linn, and certain of Old Linn's direct and indirect subsidiaries (collectively with Old Linn and LinnCo, the "Debtors"), filed voluntary petitions for reorganization under Chapter 11 of the United States Bankruptcy Code in the United States Bankruptcy Court for the Southern District of Texas (the "Court"). The Debtors' Chapter 11 cases were administered jointly under the captionIn re Linn Energy, LLC, et al., Case No. 16-60040.

        On January 27, 2017, the Court entered theOrder Confirming (I) Amended Joint Chapter 11 Plan of Reorganization of Linn Energy, LLC and its Debtor Affiliates Other Than Linn Acquisition Company, LLC and Berry Petroleum Company, LLC and (II) Amended Joint Chapter 11 Plan of Reorganization of Linn Acquisition Company, LLC and Berry Petroleum Company, LLC, which approved and confirmed the Amended Joint Chapter 11 Plan of Reorganization of Linn Energy, LLC and Its Debtor Affiliates

Other Than Linn Acquisition Company, LLC and Berry Petroleum Company, LLC (the "Plan"). The Plan became effective on February 28, 2017 (the "Effective Date").

        Pursuant to the Plan, on the Effective Date, all assets of Old Linn (other than equity interests in Linn Acquisition Company, LLC and Berry Petroleum Company, LLC) were conveyed to Linn Energy, Inc. (or a subsidiary thereof), and LinnCo, LLC and Linn Energy, LLC were wound down and liquidated. Subsequent to the effectiveness of the Plan, Linn Energy, Inc. became the reorganized successor to Old Linn. Under the Plan Supplement, as amended, filed with the Court, the Debtors assumed all executory contracts and unexpired leases with the Trust and Mesa Operating Limited Partnership as the counterparty. Furthermore, pursuant to the Plan, the royalty interests in the Hugoton Royalty Properties owned by the Trust shall be preserved and remain in full force and effect in accordance with the terms of the granting instruments or other governing documents. On April 18, 2018, Linn announced its Board of Directors' decision to separate Linn into two stand-alone public companies. On August 7, 2018, Linn completed the spin-off of Riviera through the pro rata distribution of all of the shares of Riviera's outstanding common stock to Linn's stockholders. In connection with such distribution, Linn ceased to be the operator of the Hugoton Royalty Properties, and since August 7, 2018, Riviera has operated the Hugoton Royalty Properties.

San Juan Basin Royalty Properties

        Royalty income from the San Juan Basin Royalty Properties is calculated and paid to the Trust on a state-by-state basis depending upon whether the property is situated in Colorado or New Mexico. A majority of the Royalty income from the San Juan Basin Royalty Properties is attributable to the San Juan Basin—New Mexico Properties. The majority of the natural gas produced from the San Juan Basin Royalty Properties is currently being sold on the spot market.

San Juan Basin—Colorado Properties

        Royalty Income.    Royalty income from the San Juan Basin—Colorado Royalty Properties was $113,775$101,746 during the secondfirst quarter of 2019,2020, compared to $96,582$251,494 during the secondfirst quarter of 2018.2019. This increasedecrease in Royalty income was due primarily to higherlower market prices and decreased net production volumes for natural gas offset in part by decreased net natural gas production volumes and an increase in operating costs in the secondfirst quarter of 20192020 compared to the secondfirst quarter of 2018.2019.

        Operating Costs.    Operating costs on these properties were $25,093$29,509 in the secondfirst quarter of 2019, an increase of approximately 46%2020, as compared to $17,192$31,573 in the secondfirst quarter of 2018.2019.

San Juan Basin—New Mexico Properties

        Royalty Income.    Royalty income from the San Juan Basin—New Mexico Properties was $312,106$175,986 during the secondfirst quarter of 2019 as2020, compared with Royalty income ofto $291,449 during the secondfirst quarter of 2018.2019. This increasedecrease in Royalty income was due primarily to an increasedecreased net production volumes for natural gas and natural gas liquids and increased operating and capital expenditures, offset in part by higher prices for natural gas, natural gas liquids and oil and condensate prices and increased net production volumes for natural gas liquids and oil and condensate forin the secondfirst quarter of 20192020 compared to the secondfirst quarter of 2018, offset in part by a decrease in net production volumes for natural gas and an increase in operating costs and capital expenditures during the second quarter of 2019 compared to the second quarter of 2018.2019.

        Operating Costs and Capital Expenditures.    Operating costs were $255,401$297,169 in the secondfirst quarter of 2019,2020, an increase of approximately 39%62% as compared to $183,282$183,181 in the secondfirst quarter of 20182019 due

primarily to maintenance expense reductions in the third quarter of 2017 that continued to be used by Hilcorp as estimates through the first quarter of 2019 and higher equipment repair costs in the second quarter of 2019 compared to the second quarter of 2018.2019. Capital expenditures on these properties were $14,593$27,201 in the secondfirst quarter of 2019,2020, an increase of approximately $12,776$25,384 as compared to $1,817 in

the secondfirst quarter of 20182019 due primarily to very low capital investment in the third quarter of 2017 that continued to be used by Hilcorp as an estimate through the first quarter of 2019 and the addition in 2019 of well zone recompletes that bring on new zones of production and reserves.2019.

        Following Hilcorp's acquisition of ConocoPhillips' and XTO's interests in the San Juan Basin—New Mexico Properties, there was a transition period to transfer historical information, knowledge and processes from one owner to the other. During this transition period, Hilcorp recorded estimates of revenues and expenses and made payments to the Trust based on historical amounts previously paid by ConocoPhillips, and the Trust recognized such amounts in accordance with its modified cash basis of accounting. Accordingly, Hilcorp made an estimated monthly payment of $97,150 in Net Proceeds to the Trust from September 2017 to March 2019 based upon the July 2017 production month previously paid by ConocoPhillips. In April 2019, Hilcorp began to generate actual (instead of estimated) Net Proceeds due to the Trust on a monthly basis. Hilcorp has informed the Trust that it will utilize actual revenue and expense amounts and either add or subtract reconciled historical amounts on a month-by-monthmonth by month basis, which will be recognized over time by the Trust in accordance with the Trust's modified cash basis of accounting. In December 2019, Hilcorp made the first payment to the Trust in reconciling historical amounts for one accounting month, which totaled $29,698. For the three months ended March 31, 2020, Hilcorp reconciled three additional historical amounts for the accounting months of October through December 2017, in which the Trust received additional payments of $10,578 for these months. Until all estimated historical monthly amounts received by the Trust from September 2017 to March 2019 are fully reconciled and adjusted, Net Proceeds from the San Juan—New Mexico Properties will reflect adjustments to actual current production and costs to account for historical monthly reconciliations as they are completed. Because of anticipated future adjustments, the amounts of Net Proceeds reported for the San Juan Basin—New Mexico Properties during the three monthsquarter ended June 30, 2019March 31, 2020 may not be representative of Net Proceeds that will be received in future quarters.

        Hilcorp has informed the Trust that significant incremental costs of approximately $1.1 million attributable to the Trust were incurred in 2018 with respect to a newly drilled well in the San Juan Basin—New Mexico Properties. Incremental costs attributable to the Trust will reduce the Trust's future

Net Proceeds over a period of time as adjustments are made by Hilcorp after taking into accountconsidering actual revenues as well as costs for these properties during the applicable time period. The potential impact to Net Proceeds depends upon the results of all of the reconciliation work currently being conducted by Hilcorp and is therefore uncertain. The Trust will undertake a review of the reconciliation

calculations by Hilcorp and the amount of Net Proceeds calculated and paid and intends to engage third party consultants when appropriate to assist in the Trust's review.

        Pursuant to the Trust Indenture, the Trust is not required to pay to Hilcorp any amounts that could be owed if the estimated revenue exceeded actual revenue amounts or estimated expenses were less than actual expense amountsfigures in past periods.periods, plus any additional required costs. However, Hilcorp may recover such amounts by withholding a portion or all of the Net Proceeds that would otherwise be payable to the Trust in subsequent periods. This could result in a decrease in Net Proceeds paid to the Trust and could result in a future material reductionsreduction in distributions to the Trust's unitholders.

        Net Proceeds from the San Juan Basin—New Mexico Properties for the three months ended June 30,March 31, 2020 and 2019 and 2018 were $312,106$175,986 and $291,449, respectively, which revenue accounted for approximately 53%47% and 55%40%, respectively, of the total Royalty income reported by the Trust during those periods. Net Proceeds from the San Juan Basin—New Mexico Properties for the six months ended June 30, 2019 and 2018 were $603,555 and $582,898, respectively, which revenue accounted for approximately 46% and 46%, respectively, of the total Royalty income reportedrealized by the Trust during those periods. Because of anticipated future adjustments, the amounts of Net Proceeds reported for the San Juan Basin—New Mexico Properties during the three months ended June 30, 2019March 31, 2020 may not be representative of Net Proceeds that will be received in future quarters.

Six Months Ended June 30, 2019 and 2018

Financial Review

        Royalty Income.    The Trust's Royalty income was $1,315,350 for the six months ended June 30, 2019, an increase of approximately 3% as compared to $1,277,877 for the six months ended June 30, 2018 primarily as a result of increased natural gas and oil and condensate prices, offset in part by lower net production of natural gas and natural gas liquids, an increase in operating expenses for natural gas and oil and condensate and an increase in capital expenditures in the first six months of 2019 as compared to the first six months of 2018. The Trust's interest income for the six months ended June 30, 2019 and 2018 was $16,983 and $10,400, respectively.

        General and Administrative Expense.    General and administrative expense was $97,712 and $168,854 for the six months ended June 30, 2019 and 2018, respectively. The Trustee's fees are included in general and administrative expense. The decrease for the six months ended June 30, 2019 as compared to June 30, 2018 was primarily a result of general and administrative expenses of $70,460 for December 2017 being paid by the Trust in January 2018. If the Trust had paid such expenses in

December 2017, general and administrative expenses for the six months ended June 30, 2018 would have been $98,394.

        For the six months ended June 30, 2019, the Trustee was due $237,500 for its services. The Trust paid $216,576 of this amount to the Trustee, and $20,924 was allocated to offset against interest due to the Trust under the Trust Indenture. The Trust Indenture requires that cash being held by the Trustee earn interest at 1.5% below the prime rate, which would have yielded the Trust a 4.00% annualized return from January 1, 2019 through June 30, 2019. However, due to the current interest rate environment, the Trustee was unable to obtain an account in which such an interest rate was available. In the event such an interest rate is unavailable in the future, the Trustee intends to allocate certain of its fees due to the Trust to meet the minimum interest rate payable under the Trust Indenture. In future periods the Trustee will continue to allocate a portion of the fees earned for its services to the Trust until all remaining interest due to the Trust is fully offset.

        Unreimbursed Expenses and the Contingent Reserve.    The Working Interest Owners partially reimburse the Trust each quarter for amounts paid in connection with the Trustee's services. For the six months ended June 30, 2019, the Trustee's fees were $216,576 and the Working Interest Owners reimbursed a sum of $191,794 to the Trustee, which was the same amount reimbursed for the six months ended June 30, 2018.

        As of each of the six-month periods ended June 30, 2019 and 2018, there were $0 and $14,501, respectively, of unreimbursed expenses.

        During 2011, the Trustee, acting pursuant to the Trust Indenture, withheld $1.0 million for future unknown contingent liabilities and expenses (such cumulative withholding, the "Contingent Reserve"). The Trustee reserves the right to determine whether or not to release cash reserves in future periods with respect to any reimbursement expenses. For the six months ended June 30, 2019, the Trustee increased the Contingent Reserve by (1) $56,793 of Royalty income received from BP in March 2019 after the distribution to unitholders had been announced for the month of March 2019, which Royalty income was included in the April 2019 distribution to unitholders, and (2) $434 for a duplicated general and administrative expense paid in error by the Trust in February 2019 and not refunded to the Trust until April 2019.

        For the six months ended June 30, 2019, the Trustee decreased the Contingent Reserve by (1) $434 for a duplicated general and administrative expense paid in error by the Trust in February 2019 and not refunded to the Trust until April 2019, (2) $38,364 for a cash refund of a duplicate payment from a vendor received in November 2018 and distributed to unitholders in February 2019, (3) $56,793 of Royalty income received from BP in March 2019 after the distribution to unitholders had been announced for the month of March 2019, which Royalty income was included in the April 2019 distribution to unitholders, and (4) $317 underpaid by Riviera in June 2019 due to a 2018 Ad Valorem tax under accrual but included in the June 2019 distribution to unitholders.

        As of June 30, 2019, the value of the Contingent Reserve was $999,683, which is included in cash and short-term investments.

        Distributable Income Available for Distribution.    The portion of the Trust's distributable income available for distribution each period includes the Royalty income received from the Working Interest Owners during such period, plus interest income earned to the date of distribution (if any) and increases or withdrawals from the Contingent Reserve (if any). Distributable income available for

distribution for the six months ended June 30, 2019 was $1,273,303, representing $0.6833 per unit, compared to $1,249,968, representing $0.6707 per unit, for the six months ended June 30, 2018.

Operational Review

Hugoton Royalty Properties

        Natural gas and natural gas liquids production attributable to the Hugoton Royalty Properties accounted for approximately 26% of the Royalty income of the Trust during the six months ended June 30, 2019.

        Royalty Income.    Royalty income attributable to the Hugoton Royalty Properties decreased to $346,527 for the six months ended June 30, 2019 from $451,531 for the same period in 2018 primarily due to decreased net natural gas and natural gas liquids production volumes, offset in part by an increase in natural gas and natural gas liquids prices from the Hugoton Royalty Properties in the first six months of 2019 compared to the first six months of 2018.

        Operating Costs and Capital Expenditures.    Operating costs were $618,876 during the six months ended June 30, 2019, as compared to $618,387 during the six months ended June 30, 2018. Capital expenditures attributable to the Hugoton Royalty Properties were $1 during the six months ended June 30, 2019, as compared to $2,418 during the six months ended June 30, 2018.

San Juan Basin Royalty Properties

San Juan Basin—Colorado Properties

        Royalty Income.    Royalty income from the San Juan Basin—Colorado Royalty Properties was $365,269 for the six months ended June 30, 2019, compared to $243,447 during the same period in 2018. This increase in Royalty income was due primarily to increased natural gas prices and higher net production volumes for natural gas, offset in part by an increase in operating costs in the first six months of 2019 compared to the first six months of 2018.

        Operating Costs.    Operating costs on these properties were $56,666 during the six months ended June 30, 2019, an increase of approximately 9% as compared to $52,177 during the six months ended June 30, 2018.